Methods of and apparatus for running multiple pipe strings and well packers in well packers in well bores



Oct. 27, 1964 c. 0. BROWN 3,154,145 METHODS OF AND APPARATUS FOR RUNNINGMULTIPLE PIPE STRINGS AND WELL PACKERS IN WELL BORES- Filed Nov. 25.1959 10 Sheets-Sheet 1 C/CERO C. BROWN by 2 5: 7}'), /v 811% c. c. BROWN5 4 METHODS OF AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGS AND WELLPACKERS IN WELL BORES Filed Nov. 23, 1959 lOSheets-Sheet 2 Oct. 27, 1964C/CERO 6. BROWN IN V EN TOR.

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7 METHODS 0F AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGS AND WELLPACKERS IN WELL BORES Filed Nov. 23, 1959 '10 Sheets-Sheet 3 C/CERO C.BROWN IN V EN TOR.

A TTORNE Y5 Oct. 27, 1964 c. 0. BROWN 3,154,145

METHODS OF AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGS A D wsu.PACKERS IN wsu. BORES Filed NOV. 23, 1959 10 Sheets-Sheet 4 C ICERO C.BROWN N VEN TOR.

Oct. 27, 1964 I c. c. BROWN METHODS OF AND APPARATUS FOR RUNNINGMULTIPLE PIPE STRINGS AND WELL PACKERS IN WELL BORES l0 Sheets-Sheet 5Filed NOV. 23, 1959 4a .1 B 7 i1 17 5 5/ I C/CERO 6. BROWN INVENTOR.

qi h! 3J1 W ATTORNEYS Oct. 27, 1964 3,154,145

C. BRCWN METHODS OF AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGS ANDWELL PACKERS IN WELL BORES Filed Nov. 23, 1959 1O Sheets-Sheet 6 l 72 if\M r |i i 45 60 l 62 I 1 I C/CERO 6. BROWN INVENTOR.

By g 211% Oct. 27, 1964 3,154,145

C. C. BROWN METHODS OF AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGSAND WELL PACKERS IN WELL BORES Filed Nov. 23, 1959 1O Sheets-Sheet 7C/CERO C1 BROWN IN V EN TOR. d/mwJhAm/nh BY 2 m h. 7:}.

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METHODS OF AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGS AND WELLPACKERS IN WELL BORES Filed Nov. 25, 1959 10 Sheets-Sheet 8 LillINVENTOR.

C/CERO 6, BROWN A TTOR/VE Y5 3,154,145 METHODS OF AND APPARATUS FORRUNNING MULTIPLE PIPE STRINGS AND wELL PACKERS IN wELL BORES 25, 1959 C.C. BROWN 10 Sheets-Sheet 9 Oct. 27, 1964 Filed Nov.

WLW an m mm W 1 53 Oct. 27, 1964 c. c. BROWN METHODS OF AND APPARATUSFOR RUNNING- TI PIPE STRINGS AND WELL PACKERS IN WEL 0R Filed Nov. 23,1959 10 Sheets-Sheet 10 5/ I52 /54 M5 ,4 34/4 M 46 155 4 53 /4 34/. /42/5'6 :2 AMMQ I [47 /3.9 'T

I /57 (1513. B9 B6 C/CEPO C. BROWN I INVENTOR. dvm BY 5, EMMA UnitedStates Patent METHODS OF AND APPARATUS FOR RUNNING MULTIPLE PIPE STRINGSAND WELL PACKERS IN WELL BORES Cicero (I. Brown, Houston, Tex, assignorto Brown Oil Tools, Inc, Houston, Tex, a corporation of Texas Filed Nov.23, 195%, Ser. No. 354,870 14 Claims. (Cl. 166-48) This inventionrelates to new and useful improvements in methods of and apparatus forrunning multiple pipe strings and well packers in well bores.

The invention herein is an improvement upon the method and apparatusdisclosed in my prior co-pending application, Serial No. 728,967, filedApril 16, 1958, now Patent No. 3,098,524.

It has become the general practice to simultaneously produce well fluidsfrom a plurality of producing zones which are traversed by a single wellbore. The production from each zone must be conducted to the surfacethrough an independent pipe or tubing string and therefore the producingzones must be separated or sealed off from each other by well packers.The running in and placement of the well packers and of the multipletubing strings, as well as the selective removal of said packers andstrings presents a considerable problem.

Various prior methods and apparatus have been employed but each havecertain inherent disadvantages. In some instances, the multiple stringshave been clamped or secured together and said strings having the wellpackers thereon are run simultaneously; this is satisfactory insofar aspositioning the strings and packers within the bore but because thestrings are secured together, all strings and packers must be removedsimultaneously, which is a major disadvantage. It is not possible toremove one string or one packer independently of the other.

Other prior methods and apparatus, such as those illustrated in my priorPatent No. 2,903,066 and in the aforesaid co-pending application, SerialNo. 728,967, disclose lowering the pipe strings into the Well boreindependently of each other. Such a method has the advantage ofpermitting independent handling of each string but because each stringmust be individually landed in the upper well packer, difficulty isencountered in such landing operation where more than two tubing stringsare involved. Thus, where three, four or more pipe strings are to bedisposed in final position within the bore, the advantage of separatehandling of the strings is overridden by the disadvantage of thedifficulty in efiecting proper landing.

It is further one object of this invention to provide an improved methodand apparatus for handling multiple strings and well packers whichpermits all of the strings and packers to be run simultaneously and yetpermits independent removal of each string and each packer.

An important object is to provide an improved method of handlingmultiple pipe strings so that all of the strings may be loweredsimultaneously, said method eliminating the requirement that all stringsbe clamped or otherwise secured to each other, whereby a fasterrunning-in operation may be carried out and the other disadvantagesinherent in the use of clamps are eliminated.

Another object is to provide an apparatus of the character describedwherein each string above the uppermost packer may be removedindependently of the other strings which is of decided advantage in theevent that any one of the strings need be removed for repair or forother reasons.

Another object is to provide an apparatus of the character describedwherein the uppermost packer in the well bore may be removed separatelyand independently from the other packers, whereby the requirement thatall packers be removed simultaneously as is the case where multiplestrings are clamped together is obviated.

A particular object is to provide an apparatus of the characterdescribed which includes a power-operated elevator device and apower-operated slip or spider device, with said devices beingconstructed to handle a plurality of pipe strings simultaneously. Astill further object is to provide in an apparatus of the characterdescribed, an improved multiple string sealing device for sealing otfaround a plurality of pipe strings, whereby the well is maintained undercontrol while the multiple strings are being lowered into positionwithin the well.

The construction designed to carry out the invention will be hereinafterdescribed, together with other features thereof.

The invention will be more readily understood from a reading of thefollowing specification and by reference to the accompanying drawingsforming a part thereof, wherein an example of the invention is shown,and wherein:

FIGURES 1 through 10, inclusive, are schematic views illustrating themethod of handling multiple strings having a plurality of spaced wellpackers thereon and showing the manner in which said strings and packersare run into a well bore which is traversed by a plurality of producingzones;

FIGURES 11 to 15, inclusive, are schematic views illustrating the mannerof-rernoving the multiple strings and well packers from the well bore;

FIGURE 16 is a view, partly in section and partly in elevation, showingthe two upper packers illustrated in the schematic views and detailingthe connections between said packers;

FIGURE 17 is a view, partly in section and partly in elevation of thetwo lower packers shown in the schematic illustrations and illustratingthe connection therebetween;

FIGURE 18 is a plan view of the supporting slip or spider device whichis employed during running-in of the multiple pipe strings;

FIGURE 19 is a transverse vertical sectional view taken on the line19-19 of FIGURE 18;

FIGURE 20 is a view, partly in section and partly in elevation, of thepower-operated elevator device which is employed for handling themultiple pipe strings as they are run into or removed from the well;

FIGURE 21 is a transverse sectional view of the multiple sealing unitwhich is employed to seal around the multiple strings during running-inof the strings, said view illustrating the inner element of said unitbeing lowered into position;

FIGURE 22 is a plan view of the sealing unit with the inner element inplace;

FIGURE 23 is a transverse sectional view taken on the line 2323 ofFIGURE 22;

FIGURES 24 to 27, inclusive, are elevation views which illustrate themanner of manipulating the slip or spider device during the handling ofthe multiple strings;

FIGURE 28 is an exploded view of a modified form of the slip or spiderdevice which may be used in lieu of the device illustrated in FIGURES 18and 19 and which has its slip supporting bowl formed of sectionalquadrants, one of which has been omitted for the sake of clarity;

FIGURE 29 is a plan view of the device shown in FIG- URE 28;

FIGURE 30 is a transverse sectional View taken on the line 30-450 ofFIGURE 29; and

FIGURE 31 is an enlarged sectional detail illustrating the manner ofmounting each slip member within its bowl.

General Method and Apparatus In the drawings the numeral 10 designates awell bore which traverses a plurality of well producing formations orzones, F1, F2, F3 and F4. A well casing 11 extends throughout the lengthof the well bore in the usual manner and has perforations 11a, 11b, 11cand 11d opposite the formations Fl through F4, respectively, wherebyfluid from the formations or zones may flow into the casing. A tubinghead 12 having the usual supporting seat 13 is mounted at the upper endof the casing ll above the ground level but below the derrick floor 14;the usual rotary table 15 is located above the derrick floor.

In setting up multiple production from the well bore 10, it is necessaryto dispose well packers within the well casing to separate the variousproducing zones and to lower multiple tubing strings so that well fluidsfrom each zone may be separately produced. The present method andapparatus has to do with the running-in and the removal from the bore ofa plurality of well packers and a plurality of pipe strings. For thepurpose of handling the multiple strings of pipe, 2. power elevatordevice, generally indicated at A and which will be more clearly here-'inafter described, is provided. In addition, a power-operated spiderdevice, generally indicated at B, is employed and this device will behereinafter described in further detail. The elevator device-A and thespider B are poweroperated and are arranged so that each may handle aplurality of pipe strings simultaneously. By employing power-operateddevices, the elficiency of the pipe-handling operation is greatlyincreased and it is possible to quickly and easily lower or remove aplurality of pipe strings simultaneously without the necessity ofclamping or otherwise securing said strings together.

In FIGURES l to 10, the power-operated elevator device A and thepower-operated spider device B are schematically shown. The elevatordevice is provided with four openings A1, A2, A3 and A4 with eachopening adapted to receive pipe supporting, gripping or slip elements.The spider device B is also formed with four openings B1, B2, B3 and B4through which the multiple strings extend and which are adapted toreceive pipe supporting slips. The elevator device A is, of course,adapted to be supported by the usual cable or line in which depends fromthe traveling block (not shown) of the drilling rig while the spiderdevice B is arranged to be mounted on the upper end of the rotary table15.

Referring to FIGURE 1, a first packer Pl is connected to the lowerportion of the first pipe or tubing string Tl. The upper portion of thesection of tubing T1 is supported within the opening A1 of the elevatordevice A and by means of the elevator device, packer P1 and the firstsection of tubing Tl are lowered within the well casing. After packer Plhas passed through the rotary table and into the upper portion of thewell casing, the power-operated spider device B is placed in position onthe rotary table 15. As will hereinafter appear, the spider deviceincludes an outer body 317 which rests upon the rotary table and aninner slip bowl assembly 18. The slip bowl assembly 18 is segmental sothat it may be placed in position and removed from position around themultiple pipe strings while said strings are extending into the wellbore. It is, therefore, possible to selectively place the supportingslips and bowl 18 in position to support the pipe when such support isrequired or to remove the same while the pipe string or strings aresupported by the elevator device.

When the lowermost packer Pl has moved into the upper portion of thewell casing as shown in FIGURE 2, the slip bowl assembly 18 of thespider device B is placed in position with the first section of thetubing string Tl extending through the opening B1 of device B. The slipswhich will be hereinafter described in detail are in the opening B1 andfunction to support the lowermost section of tubing T1 and the lowerpacker Pl. it is then possible to release the elevator device A from thestring T1 since the string and lower packer are supported from thespider device B.

Thereafter the second packer P2 is connected in the string Tl by meansof a safety joint S1 which will be hereinafter described. The safetyjoint will permit a disconnection at this point during removal of thepackers from the well. In addition to the connection of packer P2 withthe first pipe string T1, said packer is also connected with thelowermost section of the second pipe or tubing string T2. It is notedthat the lower end of string T2 is disposed below packer P2 andcommunicates with the area between packer P2 and the lowermost packerP1. The string T1 is rotatable within the packer P2 which will permitactuation and disconnection of the safety joint 81 when suchdisconnection is desired.

After the second packer P2 has been connected in the manner shown inFIGURE 2, the elevator device A is then connected through its pipesupporting elements with both tubing strings T1 and T2 in the mannershown in FIGURE 3. The slip bowl assembly 18 of the spider device B isremoved andthereafter the elevator device A may lower packers P1 and P2,together with the connected sections of tubing strings T1 and T2 to theposition shown in FIGURE 4.

At this time the slip bowl assembly 18 of the device B is again replacedand now tubing T1 again extends through opening Bit of the device Bwhile tubing T2 extends through opening B2. The spider device B is thusutilized to support pipe strings T1 and T2 which have the packers P1 andP2 connected therewith. Thereafter the third packer P3 may be connectedto strings T1 and T2. The string T1 extends rotatably through packer P3and has a safety joint S2 connected therein below the packer P3. Thenext section of tubing T2 has a telescoping joint 19 connected thereinand also may have a shear pin safety joint 20 disposed therein. Thepurpose of the telescoping joint is to allow setting of the packer, aswill hereinafter appear, without placing undue strain on tubing stringT2 while the purpose of the safety joint is to allow a disconnection at20 in the string T2 allowing the packer P3 to be removed separately frompacker P2.

After packer P3 is in position, the elevator device is reconnected notonly to strings T1 and T2 but also to T3 in the manner illustrated inFIGURE 5. In such instance tubing string Tl extends through the openingA1 of the elevator device, tubing string T2 extends through opening A2and tubing string T3 extends through opening A3. The slip bowl assembly18 is then removed from around the pipe strings and the elevator deviceA is employed to lower packers P1, P2 and P3 together with theirconnected pipe strings further into the well. When the fourth packer P4is to be connected in position in the pipe strings, the operation asheretofore described is repeated. That is, the slip bowl assembly 18 isplaced in position around tubing strings T1, T2 and T3 and said stringsare supported within openings B1, B2 and B3 of the spider device B.Packer P4 has tubing. string T1 rotatably extending therethrough and thesafety joint S3 is connected in the string Tl below said packer.Telescoping connections 19a and 1%, as well as shear pin. safety joints20a and 20b, are connected in strings T2 and T3 in the manner shown inFIGURE 6. At the time that these connections are made the spider deviceB is supporting all three strings and the packers P1, P2 and P3. Thelower section of the fourth tubing string T4 is connected to packer P4and has its lower end communicating with the area below said packer.

To effect lowering of the apparatus including the packer P4 into thewell, the elevator device A is again reconnected will all four strings,the strings T1 through T4 being supported in the openings Al through A4,respectively, of said elevator. The slip bowl assembly 18 of the spiderdevice B is then removed (FIGURE 7) andthe elevator device utilized tolower all four strings, together with the packers, into the well.

Because the major length of the pipe strings T1 through T4 are normallylocated above the uppermost packer, there is a period of time while thefour pipe strings are being lowered that the well would be open.Therefore, it is desirable after the four packers have been moved intothe casing that a sealing ofi around said pipes be effected. For thispurpose a sealing unit C, which will be hereinafter described in detailwith respect to FIGURES 21 to 23, is mounted on the upper end of thetubing head 12. This sealing unit has a plurality of sealing elementsC1, C2, C3 and C4 which engage around the tubing strings T1 through T4respectively. When in position, a sealing around all pipe strings iseffected and as additiOnal stands of tubing are connected in thestrings, the sealing unit C functions to maintain the upper end of thecasing closed. It might be noted that the additional stands of tubingare connected to the respective strings by handling all four stringssimultaneously with the elevator device A and the spider device B. As isusual practice, the pipe is supported by the spider when another standis connected thereto; after the stand is connected, the elevator deviceis reconnected and utilized to effect further lowering.

After the proper or desired number of stands have been connected in therespective strings, the elevator device A is utilized to support allfour strings while the sealing section of the unit C is removed.Thereafter, a pipe supporting means 21, which is schematicallyillustrated, is connected to the four strings TI through T4, after whichthe elevator device is reconnected with the upper ends of the strings inthe manner shown in FIGURE 9. The pipe supporting means may be in theform of a one-piece support from which all of the pipe strings aresuspended but preferably, this means is a sectional type of hanger, suchas shown in the patent to Allen No. 2,794,505. Each pipe string isconnected to one section of the hanger and thus may be individuallylanded or removed from the tubing head body.

The elevator device is utilized to lower the strings and packers intofinal position, the tubing supporting means 21, whether sectional orsolid, seating within the bowl 1% of the tubing head 12. Thereafter, thetubing head is flanged up by the usual closure 22 and each of the tubingstrings are connected to outlet lines in which a control valve 23 isdisposed.

With the tubing strings in final position, the packers P1 through P4 arelocated to separate the production from the producing zones F1 throughF4. As will be explained, the packers P1 through P4 are hydraulicallyactuated packers so that upon initial disposition, they are in unsetposition. This permits any desired circulation through the variousstrings and around the packers. After necessary circulation has beencarried out, the packers are properly set to separate production fromthe various zones. This final position is illustrated in FIGURE 10. Wellfluids from formation F1 are produced through string T1; production fromzone F2 is through tubing string T2; production from zone F3 is throughtubing string T3; and production from zone F4 is through tubing stringT4.

From the foregoing it will be evident that all four strings and all fourpackers may be run into the well simultaneously. The provision of thepower elevator device A and the power spider device B makes it possibleto efiiciently handle all four strings in a manner very similar to theusual way of handling a single string. It is, of course, understood thatthe proper lengths of tubing sections are disposed between the packersso that when the apparatus is in its final position (FIGURE the packersare properly located to separate flow from the various producing zones.

Removal 0 Apparatus The method of removing the pipe strings and packersis illustrated in FIGURES 11 to 15. In effecting a removal of thestrings and pipe, the closure 22 and the outlet lines at the surface arefirst removed after which the tubing supporting means 21 is removed fromthe tubing head; of course, if the means 21 is the sectional hangertype, each section is removed with the pipe string to which it isattached. Thereafter, a retrieving pipe 24 is connected through asuitable coupling 25 with the upper end of the first tubing string T1 inthe manner shown in FIGURE 11. An elevator device E is engaged with theupper end of the retrieving pipe so that said elevator is in effectconnected to the first string T1. Tubing string T1 is then rotated todisconnect the safety joint S3 which is below packer P4 and thisseparates the upper portion of tubing T1 from the lower portion of saidtubing string. Tubing T1 may thereafter undergo a limited upwardmovement relative to packer P4 and such limited upward movement effectsa release of the hydraulic pressure which maintained the packer P4 inset position, whereby said packer may return to an unset, nonsealingposition.

Following disconnection of the safety joint S3 and unsetting of packerP4, the elevator device E is utilized to remove the tubing string T1,together with the upper packer F4 from the well. The upward pull whichis effected through the upper section of string T1 will shear the safetyjoint connections Zita and 2% to thereby separate the upper portion ofstrings T2 and T3 from the lower sections thereof. Although it ispossible to remove the upper sections of strings T2, T 3 and T4simultaneously with string T1 and the packer P4, it might be desirableto remove those portions of the strings T2, T3 and T4 which are abovethe packer P4 independently of each other prior to removal of saidstring T1 and packer. Each of these strings has a threaded connectionwith the upper end of the packer P4 and this arrangement makes itpossible to individually remove the upper portions of each string T2, T3and T4 separately from the others; such individual removal should becarried out prior to removal of string T1 and packer P4. After suchremoval of strings T2, T3 and T4 is effected, then the upper portion ofstring T1 is utilized to bring packer P4 out of the hole, this operationbeing illustrated in FIG- URE 12.

After packer P4 and the upper sections of the four strings have beenremoved, the retrieving pipe 24 is again lowered into the bore and isreconnected to the lower half or" the safety joint S3 as shown in FIG-URE 13. String T1 is again rotated to break out the safety joint S2which is below packer P3. Thereafter, a limited upward movement of thestring T1 with respect to packer P3 releases pressure thereon and asubsequent upward pull on said packer disconnects the shear pin safetyjoint 2th which is in the string T2 below the packer P3. Thisdisconnects packer P? which may then be removed from the well bore bymeans of the first string T1 and the retrieving pipe 24. Those portionsof the strings T2 and T3 which are above packer P3 may be removed withsaid packer or, if desired, may be removed independently of said packersince they have threaded connection with the upper end thereof.

After packer P3 is removed, the retrieving pipe 24 is again rerun intothe well bore and is reconnected with the lower half of safety joint S2.By rotating the section 24, string Til is rotated to break out thelowermost safety joint S1 below packer P2 whereby this packer isdisconnected from the bottom packer Pl. Thereafter, string T1 is moved alimited distance relative to the packer to release pressure on saidpacker after which upward movement of the retrieving pipe and string T1effects a removal of said packer from the well bore. If desired, thatportion of the string T2 which is above packer P2 (FIG- URE 14) may beremoved independently and prior to the removal of the packer.

Following removal of packer P2, the retrieving pipe 24 is again rerun inthe manner shown in FIGURE 15 and its lower end is reconnected throughthe safety joint S1 with the remaining part of the first string T1. Thelower packer is arranged to that rotation of the string T1 effects arelease of the packer. Thus, by rotating the string, the packer P1 isreleased from its set position after which said packer may be removedfrom the well.

It will be evident that the apparatus is so arranged that the variousportions of the multiple strings may be removed independently of eachother with the result that each string can be handled separately duringthe removing operation. The arrangement of safety joints which areconnected at the proper points in the strings makes it possible toremove the packers independently of each other. By permitting theindividual handling of the strings and the independent removal of thepackers during the removing operation, it is assured that all of theapparatus may be efficiently retrieved from the well bore. The inventionthus provides an apparatus wherein all of the strings and packers arerun into position within the well bore simultaneously, which not onlyspeeds the running-in operation but also assures proper location of thepackers in position, and yet said strings and packers may beindependently handled and retrieved at any time or during the removingoperation, whereby eiiicient moval is assured.

Although independent removal of the packers is preferable, there may beinstances where it would be possible to remove more than one packer at atime. For example, referring to FIGURE 11, rotation of the string T1 maybreak out the safety joint S2 instead of safety joint S3. The joint S2is below packer P3 and an upward pull on the first string Tl would insuch case shear the safety joint 26. Thereafter, an upward pull onstring Tl would effect a removal of the two uppermost packers P4 and P3.In other instances it may be possible that the lowermost safety jointSll would break out, in which case the three packers P2, P3 and P4 mightbe removed simultaneously. Though not likely, there might be an instanceWhere, after the connection is made as in El URE 11, the initialrotation of string Tl would unset the lowermost packer P1 and asubsequent upward pull would result in an unsetting of the other threepackers so that thereafter all four packers and all four strings couldbe removed simultaneously. At any time that removal of the four stringsis being effected simultaneously, then the power-operated spider B isemployed in conjunction with the power-operated elevator A in a man nersimilar to that described with respect to the runningin operation. Thepreferable manner of removal is as illustrated in FIGURES 11 to 15 inwhich case the packers are removed independently of each other.

The Well Packers The particular well packers which are employed in thepresent apparatus are of the hydraulically-actuated type. Each packer isarranged to be lowered into the well casing in its unset position andafter said packers are properly placed, a hydraulic pressure is appliedthereto to move the packers into their set position; release of settingpressure is eifected by manipulation of the well pipe string. 7

In FIGURES 16 and 17 the particular packers which have been foundsatisfactory are shown. The packer P1 may be of the type which is morefully illustrated in my co-pending application Serial No. 69,118, filedNovember 14, 1960 now Patent No. 3,142,338. Said packer is ahydraulically-actuated type wherein pressure is applied to an actuatingpiston (not shown) within the packer to set the slips and to expand thesealing elements 26 thereof. Rotation of the string Til, which extendsinto the packer structure, effects an unsetting of the packer.

The packers P2, P3 and P4 are preferably of the type illustrated in myco-pending application Serial No. 728,967, filed April 16, 1958, nowPatent No. 3,098,524. Each of these packers includes gripping slips 27and a packer element 28, said slips and packer element being set by theapplication of internal pressure to an actuating piston element (notshown) which is located within the packer structure. Release of thehydraulic pressure in this type of packer is eifected by a longitudinalmovement of the string T1 with respect to the packer, such longitudinalmovement opening a port which relieves the pressure holding the packerin set position. Although 55 the packers illustrated in FIGURES 16 and17 have been found satisfactory for use in this apparatus, other typesof hydraulic or pressure-actuated packers may be employed in theassembly and there are presently other packers now available on the openmarket which can be used.

The particular connections between the packers and their tubing stringsare shown in FIGURES 16 and 17. The tubing string Tl extends downwardlyand is rotatable within passage 29 in packers P4, P3 and P2 and Within apassage 3t! in the lowermost packer P1. When that portion of the stringT1 immediately above packer P1 is rotated relative to the packer, thepacker is released from set position to move the packer to its unsetposition.

Connected in the string T1 between the uppermost packer 3 4- and thepacker P3 is the safety joint S3. This safety joint is a double threadjoint such as shown in my co-pending application Serial No. 743,803,filed June 23, 1958, now Patent No. 3,083,767. It is a type having bothright and left-hand threads formed on the male portion of the joint. Theupper section of tubing T1 is connected to the left-hand threads of saidmale section of safety joint S3 wh reby a right-hand rotation willdisconnect the joint S3. The right-hand threads of the safety joint aresubsequently used to permit connection of the retrieving pipe 24 byright-hand rotation to the lower portion of tubing Tl during removal ofthe apparatus.

Safety joint S2, which is of the same construction as safety joint S3,is located in the string Tl between packers P3 and P2. Similarly, safetyjoint S1, which is also of the same construction, is connected in stringT1 between packers P2 and P1.

Tubing string T2 has the lower end of that portion above packer P4.formed with left-hand threads 31 which are adapted to engage a threadedbox 32. The threaded box is formed with crisscross right and left-handthreads (similar to the threads in the safety joints S1, S2 and S3) andthe left-hand threads of string T2 connect with the left-hand threads ofsaid box 32. It is thus possible to disconnect that portion of string T2above packer P4 by right-hand rotation and since said box 32 alsoincludes right-hand threads, it is possible to reconnect string T2 by aright-hand rotation. Therefore, if it becomes necessary for any reasonto remove and replace tubing T2 after the apparatus has been located inthe well, this can be readily accomplished.

The section of tubing string T2 which extends between packers Pd and P3is formed with the telescoping connection 19a and immediately below thistelescoping section is the shear pin safety joint 20a. The telescopingsection 1% is provided in order to permit some motion of pipe string T2when packer P4 is moved to set position to thereby eleminate anexcessive strain or stretch on the upper portion of string T2. String T2is connected into the upper end of the next-below packer P3 by means ofa box 32a which is similar to the box 32 in the upper end of packer P4.A continuation of string T2 extends downwardly below packer P3 and hasthe telescoping joint 19 as well as the shear pin safety joint 20connected therein; the lower portion of this continuation of the stringT2 has connection with the packer P2 through the double threaded box32b. The extreme lower end of string T2 communicates with the areabetween packers P2 and P1.

The tubing string T3: is connected to the upper packer P4 through a box132 which is similar to the threaded boxes 32, 32a and 32b. Between theupper packer P4 and the next below packer P3, the string T3 has thetelescoping joint 1% and the shear pin safety joint 2% connectedtherein. Connection between pipe string T3 and the upper end of packerP3 is made by a double threaded box 1352a and the extreme lower end ofstring T3 communicates with the area between packers P3 and P2.

The tubing string T4 is connected in the double threaded box 232 in theupper end of packer P4 so that the portion of the string above saidpacker may be removed and replaced. The lower end of string T4communicates with the area between packers P3 and P4.

As has been described in connection with the removing operation, thefour packers and four strings are positioned in the well. If for anyreason one of the tubing strings T2, T3 or T4 develop a leak, it ispossible to remove that portion of the string above the upper packer(which is the major portion of the string) independently of the otherstrings. The disconnection is made at the connecting boxes 32, 132 or232 by a right-hand rota tion. After a particular string has beenremoved and repaired, it may be reconnected to the right-hand threads ofthe double threaded box by a right-hand rotation of the particularstring.

When the upper packer P4 is to be removed, the string T1 is rotated. Atsuch time, the lower packers P3, P2 and P1 will be in set position andwill tend to hold the lower portion of the string T1 stationary whichwill allow the uppermost safety joint S3 to break out and thereafter aslight upward movement of the upper portion of string T1 relative toupper packer P4 will release the pressure which has been holding theupper packer P4 in set position. Thereafter, a straight upward pull willshear the pins of the safety joints 20a and 20b and this will allowindependent removal of the uppermost packer F4 from the well bore.

The male double-threaded portion of safety joint S3 is left in the well,being attached to that part of string T1 which has not been removed andsubsequently the retrieving pipe 24 may be lowered downwardly andreconnected with this portion of said safety joint. Thereafter, theoperation is repeated to disconnect safety joint S2 below the packer P3and release packer P3, after which an upward pull will shear the pin ofthe safety joint 20 in the string T3. Thereafter packer P3 may beremoved.

Following removal of packer P3, the retrieving pipe 24 is reconnectedwith safety joint S2, rotation is imparted to break out the safety jointS1 and thereafter permit release and removal of packer P2. Finally, theretrieving pipe 24 is reconnected with the male portion of safety jointS1 whereby the lower packer P1 may be released and removed.

The Pipe-Handling Devices The power-operated pipe-supporting or spiderdevice B and the power-operated elevator device A, which are shownschematically in FIGURES 1 through 9, are illustrated in detail inFIGURES 18 to 20. These devices are constructed to handle a plurality ofpipe strings simultaneously whereby said pipe strings may be loweredinto or removed from the well bore at the same time.

Referring to FIGURES 18 and 19 wherein the pipesupporting or spiderdevice B is illustrated, said device includes the outer body 17 and theslip bowl assembly generally indicated at 18. The body 17 is generallycylindrical or annular and is provided with a base flange 17a wherebythe body may be supported upon the upper surface of the rotary table orother support. The body is formed with a central opening 35 which, asshown in FIGURE 19, has an inclined or tapered wall. A sectional orsegmental bowl 36 is adapted to seat within the opening 35 and, as shownin FIGURE 18, the bowl is constructed in four sections or segments andthe abutting or adjacent faces of the sections are formed ofcomplementary recesses which co-act with each other when the bowl is inplace to form the openings B1, B2, B3 and B4 through which the pipestrings are adapted to extend. The openings or bores B1 through B4 areactually circumferentially spaced around the bowl rather than disposedin transverse alignment as schematically illustrated in FIG- URES 2 to9. Each bowl section has an upper flange which overlies the body 17 andis removably secured thereto by bolts 37. With the sectionalconstruction of the bowl, the sections may be removed from and returned10 to position in the body 17 while the pipe strings are extendingthrough the body.

Each of the bores B1 through B4 has a plurality of recesses 38 which arespaced equi-distant around the circumference of the bore; each recesshas an inclined or tapered rear wall 38a. A pipe gripping element orslip 39 is movable vertically within each recess 38 and is retained andguided therein by guide grooves 38b. The number of slips within eachbore or opening is variable and as illustrated three slip elements areshown. Each slip element is slidable axially of the bore or openingwithin each recess, and it will be evident that as the slips movedownwardly along the tapered rear surface 3&1 of the recess, thegripping teeth on the inner surface of each gripping element will engagethe pipe extending through the bore. When the slip members are movedupwardly with respect to the bowl, said slips are positively movedradially outwardly by reason of the co-action of the tapered rear wall38a and guide grooves 38b with said slips so that their gripping teethdisengage the pipe. Each slip element is formed with an extension 46which projects upwardly therefrom.

For controlling the vertical movement of the said slips 39 to controlthe engagement and disengagement thereof with the pipe, a lifting member41 is provided. The lifting member is generally in the form of acircular plate and overlies the upper surface of the bowl 3a in spacedrelationship thereto. The plate is detachably secured to the upper endof a number of axial guide stems 141, each of which has its lowerportion slidable within a central bore in the bowl 1'7; the connectionbetween the plate and each stem is made by threading a nut 141a onto theupper end of the stem. Aligned with each bore B1 through 134 is anopening 42 which is formed in the lifting plate 41. Each opening 42 hasradially extending recesses 43 (FIG- URE 18) which are spacedequidistant around the opening and which communicate therewith. Eachrecess receives the extension 40 of one of the slip elements 39, saidextension projecting upwardly above the upper surface of the liftingplate; to suspend each slip element from the plate, a transverse pin 44is mounted within a transverse bore formed within the upper end of theextension 4% and the extremities of the pin overlie and engage the uppersurface of the plate. With this arrangement it is evident that as thelifting plate 41 is raised, the slip elements 39 are lifted with respectto the bowl; by reason of the radial recesses 43 within which theextensions of the slip elements are mounted, the slip members mayundergo radial as well asvertical movement, whereby the slip elementsare retracted from pipe-engaging position. When the lifting plate 41 islowered, the underside of said plate engages the upper surfaces of theslips to move the same downwardly within the inclined portion 38 of thebowl, whereby each set of slips within its respective bore is moved intopipe-engaging position.

For actuating the lifting plate 41 to raise or lower the slip elements,diametrically opposed support arms 45 extend radially from the peripheryof the plate. Each arm has its outer end removably secured to the upperend of a piston rod 46 by nuts 46a, and the lower end of said rod issecured to a piston 47 which is adapted to reciprocate within a powercylinder 48. Each power cylinder is mounted on a suitable bracket 49secured to the side of the housing 17, and fluid pressure lines 50 and51 are connected to each end of the cylinder, said lines extending to apoint remote from the device B; by controlling the application ofpressure through lines 50 and 51, the piston 47 of each cylinder may bemoved within its cylinder to effect either a raising or lowering of thelifting plate 41, whereby the position of the slip elements iscontrolled. The particular power fluid which may be air, gas or liquidwhich operates the pistons 47 is subject to variation. The use of thepower pistons permits control of the slip members from a point remotefrom the device B.

The power-operated elevator device A is illustrated in FIGURE 20. Thisdevice is preferably constructed in accordance with the device shown inmy co-pending application Serial No. 832,283, filed August 7, 1959 andnow abandoned and of which co-pending application Serial No. 208,178,filed July 2, 1962, is a continuationin-part. The construction of thedevice A is substantially the same as the spider device except that itsbowl 36a is not sectional or segmental but is substantially annular.Also, the body 17b of the elevator device does not require a base flangebut instead is provided with supporting lugs 52 which are disposed onopposite sides of the body 17b. A suitable cable or line is connected tothe supporting lugs 52 to suspend the elevator device within the derrickin the usual manner.

Other than the foregoing diiferences, the elevator device A isconstructed substantially the same as the spider device and includesgripping or slip elements 39a which are suspended from a lifting plate41a. The lifting plate is actuated by pistons 47a which have theirpiston rods 146 connected to lift anns 45a extending outwardly fromlifting plate 41a. Since the multiple pipe strings are inserted withinthe respective openings A1 through A4 of the elevator device, it is notnecessary that the bowl 36a be split, as is the case with the spiderdevice. In the case of the spider device, it is desirable that the bowlbe split so that the slip members and bowl may be removed from aroundthe pipe strings while said pipe strings extend through the bores B1through B4 of said spider device B.

The manner of using the power-operated spider device and thepower-operated elevator device in running the multiple strings into thewell bore is illustrated in detail in FIGURES 24 to 27. In thesefigures, for the sake of clarity, pipe strings T2 and T4 have beenomitted. Referring to FIGURE 24, the spider device B is shown inposition on the rotary table and in this view the lifting plate 41 isshown in raised position, whereby the slip elements 39 are innonengaging position with the pipe strings T1 and T3 which are extendingthrough the openings B1 and B3 of the bowl assembly 18. At this time theslips 39a of the elevator device A are in engaged position gripping thepipe strings T1 and T3, the lifting plate 41a of the elevator devicebeing in its lowered position. The cable or line 16 is secured to theelevator device and is suspended from the usual traveling block (notshown) of the well derrick.

With the parts in the position of FIGURE 24, the elevator device A issupporting the pipe strings and may be utilized to lower the strings T1and T3 downwardly into the well bore. As the strings are lowered so thatthe upper end of the uppermost stands is adjacent the spider device, itis desirable to support the pipe strings by the spider device so thatthe elevator A may be disengaged from the pipe and removed. Thereafter,additional stands of pipe are to be connected to the pipe strings T1 andT3.

When the upper ends of the strings T1 and T3 reach the position shown indotted lines in FIGURE 24, the pistons 47 of the spider device B areactuated to lower the lifting plate 41 and cause the slips 39 of saidspider device to engage the pipe strings T1 and T3. When so engaged, thespider device functions to support said strings and the elevator deviceis then actuated to release its slips and the elevator is then pulledupwardly away from the upper ends of the supported strings T1 and T3. Ifanother stand of pipe is to be connected in each of the strings T1 andT3, such stand is then connected, after which the elevator device isre-engaged with the added stands, the spider device is actuated torelease the slips from engagement with the pipe and the elevator deviceis utilized to again lower the strings downwardly. When the point atwhich a packer is to be connected to the strings is reached, it isnecessary that the bowl 36 of the spider device be removed in order thatthe packer may 12 be moved downwardly into the well bore and FIGURES 25to 27 illustrate the operation to permit connection of the packer andlowering thereof into the well bore.

Referring to FIGURE 25, the pipe strings T1 and T3 are supported by thespider device B with the slips 39 in pipe-engaging position. At thistime, the nuts 141a are removed from the guide stems 141 to disconnectthe lifting plate 41 from said stems; also, the pins 44 of the variousslip members are removed from the transverse bores in the respectiveextensions 40 of said slip elements so that the slips are, in effect,disconnected from their suspended position on the lifting plate. Thenuts 46a, which connect each piston rod 46 to the lifting plate 41, arealso removed whereby the lifting plate 41 is completely disconnectedfrom the rest of the assembly.

When this disconnection of the lifting plate has been accomplished, acable or line 116 is preferably secured to the outer ends of thesupporting arms 45 in the manner shown in FIGURE 25, and the line 116 isemployed to raise the lifting plate 41 and completely remove it from theassembly; if desired, the plate 41 may be removed by hand. At this timethe gripping slips or elements 39 are supporting the pipe strings T1 andT3.

After the lifting plate 41 has been removed, one of the packersindicated at P in FIGURE 26 is connected in the strings T1 and T3. Afterthe packer is in connected position, the elevator device A is re-engagedwith the upper ends of the strings T1 and T3 as shown in FIGURE 26. Nowthat the strings are supported by the elevator device, it is possible toremove the gripping elements 39 and the split bowl 36 of the device B.When the split bowl and slips are removed from device B, the fullopening of the bore 35 in the body 17 of device B is available to permitpassage of the packer P and the elevator device A is employed to lowerthe strings T1, T3 and the packer downwardly through the device B andinto the well bore.

After the packer has passed through the device B and the upper ends ofthe pipe strings T1 and T3 have moved into close proximity with thedevice B, the split bowl 336 and the slip members 39 are replaced withinthe housing or body 17 of device B (FIGURE 27) Then the line 116 isutilized to return the lifting plate 41 back into position on the upperend of the device B. As the lifting plate 41 moves back into position,its arms 45 are reconnected with the operating piston rods 46, each pin44 is replaced in the extension 41) of each slip element 39 and nuts141a are threaded onto the guide stems, whereby the device B iscompletely reassembled in the manner shown in FIGURE 24. Thereafter, theoperation is repeated in the manner heretofore described, whereby thepipe strings are alternately supported by the spider device and by theelevator device as the various stands and packers are run into the well.The arrangement of the spider device with the split bowl 36 makes itpossible to remove the split bowl assembly from the device B in order topermit the passage of the packer through device B.

Since both the devices A and B are power-operated, their slip membersmay be controlled from a remote point. For example, the valves shown ina single V having controls V1 and V2 (FIGURE 24) which control theapplication of fluid pressure to said devices may be located at someconvenient place on the derrick floor, preferably adjacent the positionof the driller. The devices A and B are adapted to handle a plurality ofstrings simultaneously, and thus the running-in time for placing all ofthe strings and all of the packers in position within the well bore isgreatly reduced. It is noted that by handling the separate multiplestrings with the single elevator unit and the unitary spider device, itis not necessary that the various strings be clamped together as theyare lowered into the hole. This not only saves considerable time duringthe running-in operation, but also has the added advantage ofsubsequently permitting independent and individual removal of thevarious sections of the strings and of the well packers.

The Sealing Unit Normally the multiple well packers are located at aconsiderable distance below the surface of the well and, therefore,after the last or uppermost packer has been started into the well bore,there is a considerable length of pipe still to be lowered into thewell; as a matter of fact this length of pipe usually constitutes themajor portion thereof. This distance may vary from 2,000 or 3,000 to asmuch as 8,000 or 10,000 feet. Since the packers are lowered into thebore in nonsealing position, it is evident that the well issubstantially open during the lowering of the strings into the bore. Ithas been found desirable to provide a sealing unit for sealing offaround the multiple strings during the lowering of the strings into thewell after the uppermost packer has already been positioned in the welland one type of sealing unit which will effectively seal off the wellbore around the multiple strings is illustrated in FIGURES 21 to 23.

The sealing unit includes an annular body or housing 60 having a baseflange 61 which is adapted to be secured to the upper end of the tubinghead 12 by suitable bolts 62. The body or housing includes an axial bore63 which may be bevelled inwardly at its lower end. An enlargedcounterbore 64 at the upper end of the body permits the provision of anannular inclined seat 65 within the bore of the body. A locking collar66 is adapted to be threaded, preferably by acme type threads 67 ontothe upper end of the body and this collar projects upwardly therefrom.The collar has an inwardly directed flange 68 on the upper portion andthe underside of the flange forms an internal annular shoulder 69 withinsaid collar. A plurality of vertical slots or recesses 70, which arespaced at circumferential points around the collar, are formed in theinner periphery of the flange 68.

A sealing assembly generally indicated at D is adapted to mount withinthe housing or body 60. The sealing assembly includes an upper block 71which is generally circular in shape and a complementary lower block 72;the blocks are secured together by suitable bolts 73 (FIG- URE 21). Theblock 71 has radially extending lugs 74 which are of a shape to engageand move through the recesses 70 provided in the collar 66. An eye 75extends upwardly from block 71 whereby a cable or line 76 may beemployed to lower the sealing assembly D into position. Molded to thelower end of the lower block 72 is a plurality of sealing sleeves 77,one of these sleeves being provided for each pipe string. As shown inFIGURE 23, the sealing sleeves each have a bore 78 which is adapted tosnugly engage the pipe string (shown in dotted lines) which extendstherethrough. The outer surface of each sealing sleeve is tapered orreduced as indicated at 79 whereby when the sleeve is in engagement withthe pipe, any pressure exteriorly of the sleeve will urge the same intotighter sealing engagement with the pipe.

In using the sealing unit, the body or housing 60 is mounted on thetubing head 12 and after the uppermost packer is in position within thewell, the multiple strings are extending upwardly therefrom and aresupported by the spider device B. At this time the sealing assembly D isengaged over the upper ends ofthe pipe strings and each pipe string ispassed through one of the sealing sleeves 77. The pipe strings are thensupported by the elevator device A and the bowl assembly 13 of thedevice B is removed; then by means of the line 76 the sealing assembly Dis lowered downwardly, sliding along the pipes until it moves intoposition within the body or housing 60. As the sealing assembly entersthe body or housing, the radially extending lugs 74 move downwardlythrough the recesses 70 in the collar 66; by the time the bevelledsurface 72a of the block 72 engages seat 65, the lugs 74 have movedbelow the level of the annular shoulder 62 formed within the collar.Thereafter, the locking collar 66 is rotated to move the recesses 70 outof alignment with the lugs 74 of the assembly (as indicated in dottedlines in FIGURE 22), after which the fast acting relatively coarsethreads 67 function as a cam to force the assembly D into tight sealingposition on the seat 65. Thus, the sealing assembly is locked againstupward displacement within the body 60. The sealing sleeves 77 are inengagement with the exterior surfaces of the pipe strings and seal offtherearound and with the sealing assembly in place, the upper end of theWell bore is closed (FIGURE 8). Whereby the pipe string may subsequentlybe lowered into the well without danger of the well getting out ofcontrol during the running-in op eration.

As previously explained, after all lengths of the pipe string have beenrun, the sealing assembly D is removed by merely first rotating thelocking collar 66 to realign the lugs 74 with recesses 70 and thenpulling the assembly upwardly over the upper ends of the pipe strings.Thereafter, the supporting block 21 which supports all pipe strings fromthe tubing head (FIGURES 9 and 10) is placed in position and the finalwell hookup is completed.

Operation From the foregoing it is believed that the operation of theapparatus and the practice of the method is obvious. By employing thepower-operated spider device which handles multiple strings and using apower-operated elevator device also adapted to handle multiple strings,it is possible to lower a plurality of strings and a plurality ofpackers within a well simultaneously. Since the spider device andelevator device are alternately used to support and lower the pipestrings, it is not necessary that the pipe strings be clamped orotherwise secured together. This results in lowering all of the packersand all of the strings into position within the well bore moreefficiently and in considerably less time than would be the case if thevarious strings were handled independently.

FIGURES 1 to 10, inclusive, illustrate the various steps of the methodwhereby the packers and strings are moved into final position. As thefirst packer P1 is lowered by means of the elevator device A (FIGURE 1),this packer is moved into the well casing 11. Each time that anotherstand is added, the spider device B is placed in position at the top ofthe well and supports that part of the string which is within the wellwhile an additional stand is added. Also, when it is desired to connectthe next packer, the device B supports the pipe which is suspended inthe well. After the second packer P2 (FIGURE 2) is connected in thestrings, the elevator device is again reconnected and the spider deviceis removed. This permits packer P2 to be lowered into the casing asshown in FIGURE 3. The operations are repeated with packer P3 and packerP4 in the manner shown in FIGURES 4 to 7.

After all packers are in the well casing, the sealing unit C is thenpositioned so that the sealing sleeves 77 of said unit seal 01f aroundeach of the pipe strings. Thereafter the desired number of stands arerun by utilizing the pipe supporting or spider device B and the elevatordevice A in the manner hereinbefore described. After all strings are inthe well and the packers are properly positioned, the upper end of thewell is closed as shown in FIGURE 10, the packers are set and productionthrough individual strings is carried out.

Although it is desirable that the pipe strings and packers be runsimultaneously, it is preferable that the strings and packers be capableof removal from the well bore individually or independently of eachother. The present method and appartus make it possible to independentlyremove the various strings and to independently remove the packers. Aspreviously described, the safety joints S3, S2 and S3 are providedbetween the packers. These safety joints are all connected in the firststring T1 and are capable of disconnection by a right-hand rotation ofthe upper portion of string T I. In addition, the safety joints 20 and20a, which are shear pin types of joints, are connected between packersP2 and P3 and packers P3 l and P4, respectively. Shear pin safety jointZtlb is also connected between packers P3 and P4.

The removal of the apparatus is illustrated in FIG- URES 11 to 15. Whenremoval is to be effected, a retrieving string 24 is connected to theupper end of the tubing string T1. If desired, strings T2, T3 and T4above the packer P4 may be individually removed prior to the time thatpacker P4 is removed. To remove packer P4, the upper portion of stringT1 is rotated to disconnect the safety joint S3. Thereafter, an upwardpull will shear the safety joints 20a and 29b and allow removal of theuppermost packer P4 as shown in FIGURE 12.

After packer P4 is removed, the retrieving string 24 is rerun andreconnected with safety joint S3. The operation is then repeated tobreak out safety joint S2 and to shear the safety joint 29 after whichpacker P3 may be removed. Thereafter, the retrieving pipe 24 is againlowered, is reconnected with safety joint S2 (FIGURE 14) and safetyjoint S1 is disconnected. This allows removal of packer P2. Finally theretrieving pipe 24 is again lowered and is connected with safety jointS1 to finally retrieve the lowermost packer P1.

The method and apparatus permits the running of any number of stringsand any number of packers in a minimum amount of time. All of theadvantages of running all of the strings and packers simultaneously andwithout requiring that the strings be connected together are obtainedand yet when the equipment is to be removed from the well, the variousportions of the strings may be removed independently and each of thepackers may be removed independently. As previously noted, there may beinstances where more than one packer can be retrieved at a time. Forinstance, referring to FIGURE 11, if the safety joint S2 should breakout upon initial rotation of the upper portion of string T1, then asubsequent upward pull on the string T1 would shear the safety joint 20and would allow packers P4 and P3 to be retrieved simultaneously.However, in most instances, it is preferable to release the variouspackers one at a time and to retrieve them independently of each other.In all cases the operator has a choice as to whether or not he wishes toretrieve the portions of the strings individually or to remove themsimultaneously with one of the packers.

Modification of the Spider Device The spider device of FIGURES 18 and 19includes the lifting plate which is in the form of a solid circularmember which must be removed by pulling the plate upwardly along thepipe strings. In order to eliminate the necessity of removing the solidlifting plate 41 by moving it upwardly over the ends of the pipestrings, as heretofore described, it is possible to construct thelifting plate in sections whereby said plate may be readily disassembledand merely removed by lateral movement in a radial direction and inFIGURES 28 to 30 such a construction, which includes a segmental liftingmember, is illustrated.

Referring to FIGURE 28, which is an exploded view of this modification,the device includes an outer housing or body 117, which is similar inconstruction to the body 17. The sectional slip bowl 136 is ofsubstantially the same construction as the slip bowl 36 of the previousform. Gripping'slips 139, of substantially the same construction as theslips 39, are provided and said slips have upward extensions 140 whichreceive the suspending pins 144a.

In place of the solid lifting plate 41, a sectional or segmental liftingplate 241 is provided. This plate includes four quadrants or sections Qwhich, when fitted together, form a substantially circular liftingmember. Each quadrant has a upstanding arcuate extension and when thequadrants are fitted together, these arcuate sections form an annularsleeve member 142 having a tapered upper end 143. A retaining ring 144is adapted to encircle this tapered portion and functions to hold thefour quadrants together so that the sleeve 142 is in close engagementwith a vertical guide stem 341, the lower portion of which is movablewithin a central bore in the bowl 136. A nut 341a threaded onto theupper end of the guide stem holds the retaining ring 144 in position onthe sleeve 14? and thereby maintains the quadrants in connectedposition. Additionally, a clamp ring 146 encircles the quadrants andalso functions to maintain said quadrants in position.

Secured to the upper end of the stem 341 is an extension 149 which hasits exterior recessed at 151 An actuating lever 151, which is pivoted at152 to a supporting post 153, has one end confined within the recess15%. Its other end is connected by a U-clamp 154 with the piston rod 46of an operating piston 47 which is movable within the cylinder 48.Movement of each quadrant of the lifting plate 241 is guided by asuitable guide pin 155 which extends upwardly from the bowl 136. Theslips 139 are suspended from openings 155 formed in the lifting memberand are guided within recesses 157 which are formed in the wall of eachbore of the bowl 136 (FIGURE 31).

In the operation of this modification, the cylinder 48 is supplied withpressure to move the piston 47 and swing the operating arm 151. Throughits connection with the guide stern 341, to which the lifting member241, formed by the quadrants Q is secured, said lifting member is raisedand lowered to raise and lower the slips. When it is desired to removethe lifting member from around the pipe strings extending therethrough,it is only necessary to first disconnect the operating lever 151 andthen remove the retaining nut 341a and retaining ring 144 whichencircles the extensions at the center of the plate. The peripheralclamp ring 1% is then removed after which the four quadrants may bemoved laterally or radially outwardly from around the pipe strings. Theslips and bowl remain in position in the manner shown in FIGURE 25whereby the pipe strings are supported but the lifting plate has beenremoved. The use of the quadrant-type lifting plate permits the easyremoval and replacement of said quadrants whereby the lifting memberformed thereby may be placed in posi tion or removed as conditionsrequire.

The foregoing disclosure and description of the invention isillustrative and explanatory thereof and various changes in the size,shape and materials, as well as in the details of the illustratedconstruction, may be made within the scope of the appended claimswithout departing from the spirit of the invention.

What I claim is:

l. A well apparatus including, a plurality of well packers, a pluralityof pipe strings having connection with said packers, a spider deviceadapted to be mounted at the surface of the well and having means fortemporarily supporting said pipe strings within the well bore,poweroperated means forming part of the spider device for controllingoperation thereof, an elevator device having means for suspending all ofsaid pipe strings, poweroperated means forming part of the elevatordevice for controlling operation of said elevator device, whereby saidelevator and said spider devices may be utilized to simultaneously lowersaid strings and packers into a well bore, and control means locatedremotely from the poweroperated means of both spider device and elevatordevice for controlling the actuation thereof from a remote location.

2. A well apparatus as set forth in claim 1, wherein each packerincludes setting means actuated by a fluid pressure for setting saidpacker, and means conducting fluid pressure from one of the pipe stringsto said setting means to set each packer after all packers and stringsare properly located Within the well bore.

3. A well apparatus including, a lower packer, an intermediate packerand an upper packer, a first tubing string extending from the surfacedownwardly through all packers and having its lower end in communicationwith the area below the lower packer, a second tubing string extendingdownwardly from the surface and having a releasable connection with theupper packer, said second string having an extension which extendsdownwardly from the upper packer and through the intermediate packerwith its lower end communicating with the area between the intermediateand lower packers, a third tubing string extending downwardly from thesurface and having releasable connection with the upper packer, saidthird tubing string having a conductor means which communicates the areabetween the upper and intermediate packers with the third tubing string,said strings and said packers being lowerable together as a unitaryapparatus into final position within the well bore, means for actuatingthe releasable connection between the second tubing string and the upperpacker by manipulation of the second string for releasing the secondstring from the upper packer to permit independent removal of saidsecond string, and means for actuating the releasable connection betweenthe third tubing string and said upper packer by manipulation of thethird tubing string for releasing the third string from the upper packerto permit independent removal of said third tubing string.

4. A well apparatus as set forth in claim 3, together with adisconnectible safety joint mounted in the first tubing string at apoint between the upper and intermediate packers, a seconddisconnectible safety joint in said first tubing string at a pointbetween the intermediate and lower packers, a disconnectible safetyjoint mounted in the extension portion of the second tubing stringbetween the upper and intermediate packers, and means actuated bymanipulation of the first tubing string for disconnecting the firstsafety joint in said first string and also for disconnecting the safetyjoint in the extension portion of the second string whereby that part ofthe first tubing string above the upper packer as well as the upperpacker may be removed from the well bore while leaving the intermediateand lower packers in said well bore.

5. A Well apparatus as set forth in claim 4, together with a retrievingpipe string which may be run into the well bore after the upper packeris removed, means operated by manipulation of the retrieving string forfirst connecting the retrieving string to the lower portion of the firststring, and thereafter disconnecting the second safety joint in saidfirst string which is below the intermediate packer, whereby theintermediate packer may be removed from the well bore while leaving thelower packer in position therein.

6. A well apparatus as set forth in claim 5, wherein the retrievingstring is subsequently lowered into the well bore after the upper andintermediate packers have been removed, and means actuated bymanipulation of said retrieving string for connecting said retrievingstring to the remaining portion of the first tubing string wherebyremoval of the lower packer may be effected.

7. The method of lowering and removing from a well bore a wellapparatus, which comprises a plurality of well packers and a pluralityof tubing strings, said method including, lowering tubing strings intothe well bore, mounting the well packers in spaced positions on saidtubing strings as said strings are being lowered into the well bore,thereafter handling the tubing strings and packers as a unitary assemblyto simultaneously lower all strings and packers to final position withinthe well bore, subsequently disconnecting the uppermost packer from theplurality of tubing strings at a point below said upper packer,thereafter removing those portions of the tubing strings above the upperpacker as well as said upper packer from the well bore, thereafterdisconnecting the next below packer from the strings at a portion belowsaid last-named packer, and removing said last-named packer and anyportions of the tubing strings thereabove from the well bore, andrepeating the disconnecting and removing steps to effect removal fromthe well bore of all of the well packers and strings.

8. The method of handling a well apparatus which comprises at least atrio of spaced well packers and at least a trio of tubing strings, saidmethod including, mounting a lower well packer on a first tubing string,suspending said first string from an elevator device and lowering saidstring and lower packer into the bore a predetermined distance,supporting said string in a spider device at the well surface anddisconnecting the elevator device from engagement with the string,mounting an intermediate packer on said first string, connecting asecond tubing string with said intermediate packer, suspending bothstrings from said elevator device, removing the spider device fromengagement with the first string, thereafter simultaneously loweringboth tubing strings having the packers thereon a further predetermineddistance within the bore, then supporting both tubing strings from thespider device, disconnecting the elevator device from engagement withsaid strings, mounting an upper packer on the first and second strings,connecting a third tubing string with said upper packer, suspending allthree tubing strings from said elevator device, removing the spiderdevice from engagement with the first and second strings, and thereaftersimultaneously lowering all three tubing strings having the well packersthereon into final position within the well bore.

9. The method as set forth in claim 8, together with the step of sealingthe area between the well bore and the three tubing strings after theupper packer has been moved into the well bore and while the lowering ofsaid tubing strings is being accomplished.

10. The method as set forth in claim 9, with the additional steps ofremoving the seal around said tubing strings after the strings andpackers are in final position, thereafter mounting well head controlequipment on the upper end of the well to close the same, setting thepackers into sealing engagement with the well bore to separateproduction zones, and thereafter producing fluids from each zone throughone of the tubing strings.

11. The method as set forth in claim 10, together with the additionalsteps of, disconnecting the upper packer from the first and secondstrings at a point below the upper packer, thereafter removing thoseportions of the first and second strings above said upper packer and thethird string as well as the upper well packer from the well bore,subsequently disconnecting the intermediate packer from the first stringat a point below the intermediate packer, removing that portion of thefirst string above the intermediate packer and the remaining portion ofthe second string as well as said intermediate packer from the wellbore, and finally retrieving the lower packer and remaining part of thefirst tubing string from said well bore.

12. The method as set forth in claim 11, wherein those portions of thefirst and second strings above the upper packer are independentlyremoved prior to removal of the upper packer, and also wherein theremaining portion of the second string is removed prior to removal ofthe intermediate packer.

13. An apparatus for lowering a plurality of well pipe strings into awell bore including, an elevator device attached to a supporting cablein the well derrick and having means for suspending a plurality of wellpipe strings therefrom, remotely located means for controlling thesuspending means whereby the pipe strings may be selectively engaged anddisengaged by said means, a spider device at the surface of the wellbore and comprising an outer housing and an inner sectional bowlassembly, said bowl assembly having a plurality of openings thereinthrough which the plurality of pipe strings may extend and each openinghaving pipe-engaging elements therein for engaging and supporting saidstrings, and remotely lo cated means for controlling the position of thepipe-engaging elements to selectively engage and disengage the elementsfrom their respective pipe strings, said elevator device and said spiderdevice being actuated to alternately support all of the pipe stringswhereby said strings may be lowered into the well bore simultaneously.

14. An apparatus as set forth in claim 13, together with means forremovably mounting the sectional bowl assembly Within the housing of thespider device, whereby said assembly may be removed from its positionsurrounding the pipe strings while said pipes are extending through thespider housing and are suspended from the elevator device.

Penick et a1 Oct. 13, R942 Rhoades Aug. 5, 1952 20 Wilson Aug. 19,Martin Oct. 7, Ilfrey et a1. May 7, Taylor Oct. 22, Palmer -2 Nov. 26,Richardson et a1 Mar. 4, Meyer Dec. 9, Moseley June 30, Brown Sept. 1,Brown Sept. 8, Brown Mar. 12, Brown July 23,

1. A WELL APPARATUS INCLUDING, A PLURALITY OF WELL PACKERS, A PLURALITYOF PIPE STRINGS HAVING CONNECTION WITH SAID PACKERS, A SPIDER DEVICEADAPTED TO BE MOUNTED AT THE SURFACE OF THE WELL AND HAVING MEANS FORTEMPORARILY SUPPORTING SAID PIPE STRINGS WITHIN THE WELL BORE,POWEROPERATED MEANS FORMING PART OF THE SPIDER DEVICE FOR OPERATED MEANSFORMING PART OF THE SPIDER DEVICE FOR CONTROLLING OPERATION THEREOF, ANELEVATOR DEVICE HAVING MEANS FOR SUSPENDING ALL OF SAID PIPE STRINGS,POWEROPERATED MEANS FORMING PART OF THE ELEVATOR DEVICE FOR CONTROLLINGOPERATION OF SAID ELEVATOR DEVICE, WHEREBY SAID ELEVATOR AND SAID SPIDERDEVICES MAY BE UTILIZED TO SIMULTANEOUSLY LOWER SAID STRINGS AND PACKERSINTO A WELL BORE, AND CONTROL MEANS LOCATED REMOTELY FROM THEPOWEROPERATED MEANS OF BOTH SPIDER DEVICE AND ELEVATOR DEVICE FORCONTROLLING THE ACTUATION THEREOF FROM A REMOTE LOCATION.